A novel CO2 and pressure responsive viscoelastic surfactant fluid for fracturing
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Fracturing fluid
In the process of fracturing in tight reservoirs, viscoelastic surfactant (VES) fracturing fluid has many advantages that can significantly increase the recovery of tight oil. However, there is a risk of formation blockage due to heavy emulsification in the formation. In this study, a VES microemulsion (VES-M) system with low reservoir damage and high oil displacement efficiency is constructed using VES fracturing fluid and isobutanol. The average particle size in the fluid is only 3% to 10% of the average pore size of the tight reservoir, and the formation damage is 16.00%. The new fluid can achieve ultra-low interfacial tension (IFT) with Winsor type III microemulsion. Compared with slickwater fracturing fluid and formation water, the new fluid can filtrate deeper into the matrix and increase the oil recovery by 7.20%~11.32% during the flowback process. This study provides a possibility for the field application of VES fracturing fluid in tight reservoirs and new insights into the effects and rules of employing the VES-M system to enhance tight oil recovery.
Tight oil
Fracturing fluid
Tight gas
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This study examines the degradation of agglomerate particles in treated produced water used for hydraulic fracturing in the Bakken Formation. By analyzing d90 values and pump speeds from different manufacturers, the research quantifies particle size reduction rates, revealing how degradation contributes to pore throat blocking in tight formations. The study found that agglomerate particles in hydraulic fracturing fluids ranged from 9 to 85 microns in size, with degradation occurring most rapidly within the first five minutes of pump action. As time progresses, degradation slows, indicating that pore clogging is most likely at the beginning of the fracturing process. The research emphasizes that pump speed is a critical factor in determining the rate of particle degradation. To minimize formation damage, it is recommended to scale up particle size and use coarser particles in suspension. However, both large and small particles pose risks: larger particles can reduce porosity, while smaller particles may penetrate pore throats and form internal filter cakes. The study highlights the importance of selecting the appropriate pump speed and particle size distribution to optimize fracturing fluid design, maintain formation permeability, and reduce the risk of formation damage. Lower pump speeds and fewer coarse particles are advised to avoid pore clogging during the fracturing process.
Fracturing fluid
Agglomerate
Particle (ecology)
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Hydraulic fracturing is one of the most important stimulation for our unconventional reservoir development. In this article, we analyze environmental impact from fracturing fluid. We also give measures to control contaminations. It contains enhancing recovery of fracturing fluid and strictly treatment of fluids.
Fracturing fluid
Well stimulation
Water contamination
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Hydraulic fracturing is carried out using two broad classes of fracturing materials: fracturing fluid and proppants. Fluids currently being used for fracture treatments in shale wells are water-based fluids or mixed slickwater fracturing fluids, which are water-based fluids mixed with friction-reducing additives, primarily potassium chloride. Many factors are considered in the choice of fracturing fluid, additives, and propping agents. The process of selection though is a subjective process and consideration is given to formation evaluation, laboratory test results, and project experience. Slickwater fracturing is probably the most basic and most common form of well stimulation in unconventional gas. Additives are utilized in hydraulic fracturing operations and the common classes or subcategories of additives include fluid-loss additives, clay stabilizers, gel breakers, bactericides and/or biocides, and pH control chemicals. The purpose of any acidizing is to improve the productivity or injectivity of a well and the formation.
Fracturing fluid
Well stimulation
Shale Gas
Tight gas
Comminution
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Oil and Gas Well hydraulic fracturing technology is an effective way to transform oil layer,effective measure for stimulation of oil,gas and water-injection well.Fracturing fluid in hydraulic fracturing operations play an important role,suspending propant ability is good or bad is related to the success of fracturing.In this paper,suspending propant ability of water-based fracturing fluid most commonly used guar gum fracturing fluid and the clean fracturing fluid YCQJ-1 have been compared for fracturing treatment to provide important technical parameters.
Fracturing fluid
Well stimulation
Guar gum
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Hydraulic fracturing is a potentially promising stimulation technology employed for enhancing gas productivity and energy efficiency of low‐permeability hydrate reservoirs. At present, most studies in the field of hydrate reservoir fracturing have mainly focused on the fracturing feasibility and recovery efficiency without considering the effects of fracturing fluids on hydrate reservoirs. However , fracturing fluid will inevitably invade hydrate reservoirs driven by high fracturing pressure, which may cause hydrate phase transitions and consequently affects fracturing. In this study, the dynamic process of fracturing fluid invasion into hydrate reservoir was simulated using the TOUGH+HYDRATE software, primarily focusing on the differences between the fracturing fluid invasion into the gas hydrate-bearing layer (GHBL), three-phase layer (TPL), and free gas layer (FGL). The results showed that a secondary hydrate ring around the fracture was formed by the fracturing fluid/free water and free gas within the reservoir during fracturing fluid invasion into the TPL and FGL, which was mainly driven by the large driving force exerted by high fracturing pressure. But the exothermic reaction of hydrate formation can provide negative feedback to the formation and expansion of the secondary hydrate ring, leading to a state of phase equilibrium in the secondary hydrate formation region and the outward expansion of the secondary hydrate ring in a “three-phase equilibrium” mode. Moreover, an increase in the fracturing pressure led to a higher invasion rate, a larger invasion range, and larger regions of secondary hydrate formation . It should be noted that secondary hydrate formation did not occur during fracturing fluid invasion into GHBL because of the absence of free gas, and fracturing fluid invasion into GHBL only affected reservoir temperature and pressure, which was similar to the fracturing fluid invasion into unconventional oil and gas layers.
Fracturing fluid
Clathrate hydrate
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This paper presents a new sand fracturing technology of hydraulic jet,which needs fracturing fluids with new special performances,so the fracturing fluid system for the new process was studied in laboratory by optimizing the formula of fracturing fluid system,cross-linking agent composition,crosslinking ratio,and etc.A developed fracturing fluid formula and field application technology meets the new process.The lab performance evaluation shows that the fracturing fluid can meet the requirement for carrying sand after shearing highly fracturing fluid by hydraulic jet layer and sand fracturing.The technology has been successfully applied in Guangan,Hechuan and other blocks of Xujiahe in Sichuan high-angle wells,horizontal well hydraulic fracturing jet layer.The natural gas production increases accumulatively 11.1365×104 m3/d.
Fracturing fluid
Shearing (physics)
Well stimulation
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A new type of synthetic polymer fracturing fluid with low formation damage is introduced in this paper. The gellant FA-200A used in this new fracturing fluid system is almost free of insoluble materials. The pH value of the crosslink is 5-6 using AC-12A as the cross linking agent. This new fracturing fluid system is suitable for use in both conventional hydraulic fracturing and liquid N_2 foamed fracturing. Application temperatures of this new fracturing fluid system are 50-90 ℃. Comparing with guar fracturing fluid, the new fracturing fluid system eliminates the use of bactericides. The cost of this fracturing fluid is lower than clear fracturing fluids.
Fracturing fluid
Tight gas
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Introducing several new types of fracturing fluid which consist the low damage fracturing fluid (HPF), a new clean fracturing fluid (EFAS), alcohol radical fracturing fluid, summarizing several new technology such as floating prop pant fracturing technology, end sand strip controlling seam height fracturing technology, hydraulic injection layer fracturing technology and seam height controlled technology during fracturing, analyzing the corresponding fracturing Modification Techniques of different reservoir types. Developing the hydraulic fracturing technology for their oil fields based on the study at home and abroad is proposed.
Fracturing fluid
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While hydraulic fracturing has undeniably improved the production from oil and gas reservoirs, this technology is not without limitations. The primary hurdles lie in the areas of proppant transport, fluid rheology, and stress management. Despite the extensive research conducted in this domain, there remains a considerable amount of work to be done for comprehensive solutions that account for the complex interactions among fracturing fluid, proppant distribution, and geomechanical conditions. Achieving this will then make room for a holistic and efficient hydraulic fracturing strategy.
Fracturing fluid
Shale Gas
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